Downhole separator

ABSTRACT

There is provided a downhole apparatus configured for integration within a gas-depleted fluid production assembly of a reservoir fluid production assembly disposed within a wellbore string passage of a wellbore string that is emplaced within a wellbore, for modifying the gas-depleted fluid production assembly such that improved gas separation characteristics are obtained.

CROSS-REFERENCE TO RELATED APPLICATION

This application is claims the benefits of priority to U.S. ProvisionalPatent Application No. 63/342,412, filed May 16, 2022, titled DOWNHOLESEPARATOR, the contents of which are hereby expressly incorporated intothe present application by reference in their entirety.

FIELD

The present disclosure relates to mitigating gas interference withdownhole pump operation during hydrocarbon production.

BACKGROUND

Reservoir fluids often contain entrained gases and solids. In producingreservoir fluids containing a relatively substantial fraction of gaseousmaterial, the presence of such gaseous material hinders production bycontributing to sluggish flow, and interfering with pump operation. Aswell, the presence of solids interferes with pump operation, includingcontributing to erosion of mechanical components.

Separators are provided help remedy or mitigate downhole pump gasinterference during hydrocarbon production. However, separators oftenoccupy relatively significant amounts of space within a wellbore,rendering efficient separation of gaseous material that is entrainedwithin the reservoir fluid difficult. Some separators are complexstructures and are associated with increased material and manufacturingcosts. Accordingly, efficient and cost effective separation of gaseousmaterial that is entrained within the reservoir fluid is desirable.

SUMMARY

In one aspect, there is provided a downhole apparatus configured forintegration within a gas-depleted fluid production assembly of areservoir fluid production assembly disposed within a wellbore stringpassage of a wellbore string that is emplaced within a wellbore, theintegration is with effect that a apparatus-defined flow conductorconfiguration is established;

wherein:

-   -   the gas-depleted fluid production assembly co-operates with the        wellbore string 108 to define a flow diverter;    -   the flow diverter defines a reservoir fluid conductor        configuration, a separation zone, a downwardly-conducting flow        conductor configuration, and an upwardly-conducting flow        conductor configuration;    -   the reservoir fluid conductor configuration, the separation        zone, the downwardly-conducting flow conductor configuration,        and the upwardly-conducting flow conductor configuration are        co-operatively configured such that:        -   while reservoir fluid flow is being received within a            reservoir fluid-receiving zone, of the wellbore string            passage, from the subterranean formation, the reservoir            fluid flow is conducted upwardly to the gas separation zone            via the reservoir fluid conductor configuration, with effect            that the reservoir fluid flow becomes emplaced within the            separation zone;        -   while the reservoir fluid flow is disposed within the            separation zone, in response to buoyancy forces, gaseous            material is separated from the reservoir fluid flow, with            effect that an upwardly-flowing gas-enriched reservoir fluid            flow and a downwardly-flowing gas-depleted reservoir fluid            flow are obtained, and such that the downwardly-flowing            gas-depleted reservoir fluid flow is received and conducted            by the downwardly-conducting flow conductor configuration;            and        -   while the gas-depleted reservoir fluid flow is being            conducted in a downwardly direction by the            downwardly-conducting flow conductor configuration, the            gas-depleted reservoir fluid flow is diverted such that an            upwardly gas-depleted reservoir fluid flow is being            conducted through the upwardly-conducting flow conductor            configuration for suppling a pumping assembly of the            reservoir fluid production assembly;    -   the separation zone extends through a separation zone-defining        wellbore section that extends from a lower wellbore cross        section to an upper wellbore cross section;    -   the apparatus-defined flow conductor configuration defines at        least a portion of the upwardly-conducting flow conductor        configuration;    -   at least a portion of the apparatus-defined flow conductor        configuration includes a flow interference-mitigating conductor        configuration that extends through the separation zone-defining        wellbore section; and    -   the flow interference-mitigating conductor configuration defines        an eccentrically-disposed conductor configuration, wherein the        eccentrically-disposed conductor configuration is disposed        eccentrically relative to the central longitudinal axis of the        wellbore string passage.

In another aspect, there is provided a kit comprising the apparatus, asdescribed above, and an elongated member for connection to a portion ofthe apparatus-defined flow conductor configuration and also forconnection to a separator of the gas-depleted fluid production assembly,such that, while the apparatus is integrated within the gas-depletedfluid production assembly of a reservoir fluid production assembly, theseparator is supported by the apparatus-defined flow conductorconfiguration.

In another aspect, there is provided a method for producing hydrocarbonmaterial, from an oil reservoir within a subterranean formation, via asystem includes a production string, including a reservoir fluidproduction assembly, disposed within a wellbore string passage of thewellbore string, wherein the reservoir fluid production assemblyincludes:

-   -   a gas-depleted fluid production assembly; and    -   a pumping assembly;        wherein:    -   the gas-depleted fluid production assembly co-operates with the        wellbore string to define a flow diverter;    -   the flow diverter defines a reservoir fluid conductor        configuration, a separation zone, a downwardly-conducting flow        conductor configuration, and an upwardly-conducting flow        conductor configuration;    -   the reservoir fluid conductor configuration, the separation        zone, the downwardly-conducting flow conductor configuration,        and the upwardly-conducting flow conductor configuration are        co-operatively configured such that:        -   while reservoir fluid flow is being received within a            reservoir fluid-receiving zone, of the wellbore string            passage, from the subterranean formation, the reservoir            fluid flow is conducted upwardly to the gas separation zone            via the reservoir fluid conductor configuration, with effect            that the reservoir fluid flow becomes emplaced within the            separation zone;        -   while the reservoir fluid flow is disposed within the            separation zone, in response to buoyancy forces, gaseous            material is separated from the reservoir fluid flow, with            effect that an upwardly-flowing gas-enriched reservoir fluid            flow and a downwardly-flowing gas-depleted reservoir fluid            flow are obtained, and such that the downwardly-flowing            gas-depleted reservoir fluid flow is received and conducted            by the downwardly-conducting flow conductor configuration;            and        -   while the gas-depleted reservoir fluid flow is being            conducted in a downwardly direction by the            downwardly-conducting flow conductor configuration, the            gas-depleted reservoir fluid flow is diverted such that an            upwardly gas-depleted reservoir fluid flow is being            conducted through the upwardly-conducting flow conductor            configuration for suppling the pumping assembly;    -   the separation zone extends through a separation zone-defining        wellbore section that extends from a lower wellbore cross        section to an upper wellbore cross section;    -   the gas-depleted fluid production assembly includes a separator;    -   the separator defines a separator-defined flow conductor        configuration the separator-defined flow conductor configuration        includes a separator-defined upwardly-conducting flow conductor        configuration (“separator-defined UCFCC”), and the        separator-defined UCFCC defines a portion of the        upwardly-conducting flow conductor configuration; and        wherein the method comprises:    -   producing hydrocarbon material via the system;    -   suspending the producing; and    -   while the producing is suspended, integrating a        separator-co-operating apparatus within the gas-depleted fluid        production assembly such that a modified system is obtained;    -   wherein:        -   the separator-co-operating apparatus defines an            apparatus-defined flow conductor configuration;        -   at least a portion of the apparatus-defined flow conductor            configuration includes a flow interference-mitigating            conductor configuration;        -   the flow interference-mitigating conductor configuration            defines an eccentrically-disposed conductor configuration;        -   the integration of the separating co-operating apparatus            within the gas-depleted fluid production assembly includes            emplacement between the pumping assembly and the separator,            and is with effect that:            -   the apparatus-defined flow conductor configuration is                disposed in flow communication with the                separator-defined UCFCC, such that the apparatus-defined                flow conductor configuration is disposed for receiving                the gas-depleted reservoir fluid flow being conducted by                the separator-defined UCFCC;            -   the apparatus-defined flow conductor configuration is                disposed for supplying the gas-depleted reservoir fluid                flow to the pumping assembly;            -   the flow interference-mitigating conductor configuration                extends through the separation zone-defining wellbore                section; and            -   the eccentrically-disposed conductor configuration is                disposed eccentrically relative to the central                longitudinal axis of the wellbore string passage.

BRIEF DESCRIPTION OF THE DRAWINGS

Reference will now be made, by way of example, to the accompanyingdrawings which show example embodiments of the present application, andin which:

FIG. 1 is a schematic illustration of an embodiment of a reservoir fluidproduction system, including a first embodiment of a gas-depleted fluidproduction assembly, disposed within a wellbore;

FIG. 2 is a schematic illustration of an embodiment of a reservoirproduction system, including a second embodiment of a gas-depleted fluidproduction assembly, disposed within a wellbore;

FIG. 3 is a schematic illustration of an embodiment of a reservoirproduction system, including a third embodiment of a gas-depleted fluidproduction assembly, disposed within a wellbore;

FIG. 4 is a schematic illustration of an embodiment of a reservoir fluidproduction system, including a fourth embodiment of a gas-depleted fluidproduction assembly, disposed within a wellbore;

FIG. 5 is a schematic illustration of an embodiment of a separatorco-operating apparatus that is integrated within the embodiments of thegas-depleted fluid production assembly illustrated in FIGS. 1, 2, and 3;

FIG. 6 is a schematic illustration of an elongated member (e.g. rigidbar) supporting a separator of the embodiments of the gas-depleted fluidproduction assembly illustrated in FIGS. 1, 2, and 3 ;

FIG. 7 is a schematic illustration of an embodiment of a separatorco-operating apparatus that is integrated within the embodimentillustrated in FIG. 4 ;

FIG. 8 is an enlarged view of Detail “A” in FIG. 4 ; and

FIG. 9 is a top plan view of the production system, taken along thecross-section “XC” in FIG. 8 .

Similar reference numerals may have been used in different figures todenote similar components.

DESCRIPTION OF EXAMPLE EMBODIMENTS

Referring to FIGS. 1 to 7 , there are provided systems 10 for producinghydrocarbon material from an oil reservoir within a subterraneanformation 100.

A wellbore 102 of a subterranean formation can be straight, curved orbranched. The wellbore can have various wellbore sections. A wellboresection is an axial length of a wellbore 102. A wellbore section can becharacterized as “vertical” or “horizontal” even though the actual axialorientation can vary from true vertical or true horizontal, and eventhough the axial path can tend to “corkscrew” or otherwise vary. In someembodiments, for example, the central longitudinal axis of the passageof a horizontal section is disposed along an axis that is between about70 and about 110 degrees relative to the vertical, while the centrallongitudinal axis of the passage of a vertical section is disposed alongan axis that is less than about 20 degrees from the vertical “V”, and atransition section is disposed between the horizontal and verticalsections.

“Reservoir fluid” is fluid that is contained within an oil reservoir.Reservoir fluid can be liquid material, gaseous material, or a mixtureof liquid material and gaseous material. The reservoir fluid includeshydrocarbon material, such as oil, natural gas condensates, or anycombination thereof. The reservoir fluid can also contain water. Thereservoir fluid can also include fluids injected into the reservoir foreffecting stimulation of resident fluids within the reservoir.

The term “fluid conductor configuration” refers to a configuration whichconducts fluid. The configuration can be: (a) a single conductor, (b) aplurality of parallel conductors, (c) a network of interconnectedconductors, or any combination of (a), (b), and (c).

A wellbore string 108 is emplaced within the wellbore 102 forstabilizing the subterranean formation 100. In some embodiments, forexample, the wellbore string 108 also contributes to effecting fluidicisolation of one zone within the subterranean formation 100 from anotherzone within the subterranean formation 100.

The fluid productive portion of the wellbore 102 may be completed eitheras a cased-hole completion or an open-hole completion.

With respect to a cased-hole completion, in some embodiments, forexample, a wellbore string 108, in the form of a wellbore casing thatincludes one or more casing strings, each of which is positioned withinthe wellbore 102, having one end extending from the wellhead 106, isprovided. In some embodiments, for example, each casing string isdefined by jointed segments of pipe. The jointed segments of pipetypically have threaded connections.

Typically, a wellbore 102 contains multiple intervals of concentriccasing strings, successively deployed within the previously run casing.With the exception of a liner string, casing strings typically run backup to the surface 104. Typically, casing string sizes are intentionallyminimized to minimize costs during well construction. Generally, smallercasing sizes make production and artificial lifting more challenging.

For wells that are used for producing reservoir fluid, few of theseactually produce through the wellbore casing. This is because producingfluids can corrode steel or form undesirable deposits (for example,scales, asphaltenes or paraffin waxes) and the larger diameter can makeflow unstable. In this respect, a production string is usually installedinside the last casing string. The production string is provided toconduct reservoir fluid, received within the wellbore, to the wellhead106. In some embodiments, for example, the annular region between thelast casing string and the production string may be sealed at the bottomby a packer.

The wellbore 102 is disposed in flow communication (such as throughperforations provided within the installed casing or liner, or by virtueof the open hole configuration of the completion), or is selectivelydisposable into flow communication (such as by perforating the installedcasing, or by actuating a valve to effect opening of a port), with thesubterranean formation 100. When disposed in flow communication with thesubterranean formation 100, the wellbore 102 is disposed for receivingreservoir fluid flow from the subterranean formation 100, with effectthat the system 10 receives the reservoir fluid.

In some embodiments, for example, the wellbore casing is set short oftotal depth. Hanging off from the bottom of the wellbore casing, with aliner hanger or packer, is a liner string. The liner string can be madefrom the same material as the casing string, but, unlike the casingstring, the liner string does not extend back to the wellhead 106.Cement may be provided within the annular region between the linerstring and the oil reservoir for effecting zonal isolation (see below),but is not in all cases. In some embodiments, for example, this liner isperforated to effect flow communication between the reservoir and thewellbore. In some embodiments, for example, the production tubing stringmay be engaged or stung into the liner string, thereby providing a fluidpassage for conducting the produced reservoir fluid to the wellhead 106.

An open-hole completion is established by drilling down to the producingformation, and then lining the wellbore (such as, for example, with awellbore string 108). The wellbore is then drilled through the producingformation, and the bottom of the wellbore is left open (i.e. uncased),to effect flow communication between the reservoir and the wellbore.

The system 10 receives, via the wellbore 102, the reservoir fluid flowfrom the subterranean formation 100. As discussed above, the wellbore102 is disposed in flow communication (such as through perforationsprovided within the installed casing or liner, or by virtue of the openhole configuration of the completion), or is selectively manipulatedinto flow communication (such as by perforating the installed casing, orby actuating a valve to effect opening of a port), with the subterraneanformation 100. When disposed in flow communication with the subterraneanformation 100, the wellbore 102 is disposed for receiving reservoirfluid flow from the subterranean formation 100, with effect that thesystem 10 receives the reservoir fluid.

In some embodiments, for example, the system 10 includes a productionstring, including a reservoir fluid production assembly 200, disposedwithin a wellbore string passage 110 of the wellbore string 108. Thereservoir production assembly 200 includes a gas-depleted fluidproduction assembly 400 and a pumping assembly 300.

The pumping assembly 300 includes a pump 301 and a pressurizedgas-depleted reservoir flow conductor 500. The pump 301 includes asuction 301A (or “intake”) and a discharge 301B. The gas-depleted fluidproduction assembly 400 is fluidly coupled to the pump suction 301A. Thepressurized gas-depleted reservoir flow conductor 500 is fluidly coupledto the pump discharge 301B.

In some embodiments, for example, the pump 301 is a rod pump 301. Therod pump 301 includes a conveyor, such as a rod or a rod string,extending through the pressurized gas-depleted reservoir fluid conductor500, and connected to surface equipment which causes reciprocatingmovement of the conveyor. In some embodiments, for example, the surfaceequipment includes a prime mover (e.g. an internal combustion engine ora motor), a crank arm, and a beam. The prime mover rotates the crankarm, and the rotational movement of the crank arm is converted toreciprocal longitudinal movement through the beam. In some embodiments,for example, the prime mover is a pumpjack. The beam is attached to apolished rod by cables hung from a horsehead at the end of the beam. Thepolished rod passes through a stuffing box and is attached to theconveyor. Accordingly, the surface equipment effects reciprocatinglongitudinal movement of the conveyor, and further defines the upper andlower displacement limits of the conveyor. Reservoir fluid is producedto the surface in response to reciprocating longitudinal movement of therod by the pumpjack.

A reservoir fluid-receiving zone 602 is disposed within the wellborestring passage 110 for receiving reservoir fluid flow 702 that isconducted from the subterranean formation 100 and into the wellbore 102.In this respect, reservoir fluid flow 702, from the subterraneanformation 100, is received by the reservoir fluid-receiving zone 602. Insome embodiments, for example, the reservoir fluid-receiving zone 602 isdisposed within a horizontal section of the wellbore 102.

The gas-depleted fluid production assembly 400 co-operates with thewellbore string 108 to define a flow diverter 402. The flow diverter 402defines a reservoir fluid conductor configuration 403, a separation zone405, a downwardly-conducting flow conductor configuration 404, and anupwardly-conducting flow conductor configuration 406.

The reservoir fluid conductor configuration 403, the separation zone405, the downwardly-conducting flow conductor configuration 404, and theupwardly-conducting flow conductor configuration 406 are co-operativelyconfigured such that:

-   -   while reservoir fluid flow 702 is being received within a        reservoir fluid-receiving zone 602, of the wellbore string        passage 110, from the subterranean formation 100, the reservoir        fluid flow 702 is conducted upwardly to the gas separation zone        405 via the reservoir fluid conductor configuration 403, with        effect that the reservoir fluid flow becomes emplaced within the        separation zone 405;    -   while the reservoir fluid flow is disposed within the separation        zone 405, in response to buoyancy forces, gaseous material is        separated from the reservoir fluid flow 702, with effect that an        upwardly-flowing gas-enriched reservoir fluid flow 706 and a        downwardly-flowing gas-depleted reservoir fluid flow 708A are        obtained, and such that the downwardly-flowing gas-depleted        reservoir fluid flow 708A is received and conducted by the        downwardly-conducting flow conductor configuration 404; and    -   while the gas-depleted reservoir fluid flow 708A is being        conducted in a downwardly direction by the downwardly-conducting        flow conductor configuration 404, the gas-depleted reservoir        fluid flow is diverted such that an upwardly gas-depleted        reservoir fluid flow 708 is being conducted through the        upwardly-conducting flow conductor configuration 406 for        suppling the suction 301A of the pump 301.

The gas separation zone 405 has a sufficiently large cross-sectionalflow area, relative to that of the reservoir fluid conductorconfiguration 403 through which the reservoir fluid-derived flow isconducted from the receiving zone 602, with effect that the flowrate ofthe reservoir fluid flow 702 is sufficiently reduced so as to permit theseparation.

In some embodiments, for example, the separation zone 405 extendsthrough a separation zone-defining wellbore section 4055. The wellboresection 4055 extends from a lower wellbore cross section 4052 to anupper wellbore cross section 4053.

In some embodiments, for example, the gas separation zone 405 isdisposed within a passage of the wellbore 102 whose central longitudinalis disposed along an axis that is disposed at an acute angle of lessthan about 45 degrees from the vertical “V”, such as, for example, lessthan about 35 degrees from the vertical “V”.

The pump suction 301A defines a flow receiving communicator 301AA (e.g.inlet port) for receiving the gas-depleted reservoir fluid flow 708being supplied by the upwardly-conducting flow conductor configuration406. The pump 301 is effective for pressurizing the upwardly-flowinggas-depleted reservoir fluid flow 708B that is supplied to the suction301A of the pump 301, with effect that the pressurized gas-depletedreservoir fluid flow 710 is discharged via the pump discharge 301B andreceived by the pressurized gas-depleted reservoir flow conductor 500,for flow to the surface via the pressurized gas-depleted reservoir flowconductor 500. In this respect, the pump discharge 301B defines a flowdischarging communicator 301BB (e.g. outlet port) for effectuating thedischarging of the pressurized gas-depleted reservoir fluid flow 710.

In this respect, the gas-depleted fluid production assembly 400 iseffective for separating the gas-depleted reservoir fluid flow 708 fromthe reservoir fluid-derived fluid flow 704, and supplying thegas-depleted reservoir fluid flow 708 to the pump 301, for pressurizingthe gas-depleted reservoir fluid flow 708 by the pump 301 for flow tothe surface via the flow conductor 500.

In parallel, the gas-enriched reservoir fluid flow 706 is conductedupwardly to the surface 104 via a gas-enriched reservoirfluid-conducting passage 112 defined within the wellbore 102. In thisrespect, the gas-enriched reservoir fluid-conducting passage 112 isdisposed uphole relative to, and in flow communication with, theseparation zone 405.

The reservoir fluid produced from the subterranean formation 100, viathe wellbore 102, including the gas-depleted reservoir fluid, thegas-enriched reservoir fluid, or both, may be discharged through thewellhead 106 to a collection facility, such as a storage tank within abattery.

In this respect, a fluid passage 900 is defined within the wellbore 102,extending from the reservoir fluid-receiving zone 402 to the pump 301,for supplying the gas-depleted reservoir fluid flow 708, derived fromthe reservoir fluid flow 702 received by the receiving zone 402, to thepump 301, for pressurization by the pump 301 for flow to the surface 104as the flow 710 via the pressurized gas-depleted reservoir flowconductor 500. The fluid passage 900 is defined by a fluid conductorconfiguration which includes the reservoir fluid conductor configuration403, the separation zone 405, the downwardly-conducting flow conductorconfiguration 404, and the upwardly-conducting flow conductorconfiguration 406.

In some embodiments, for example, a separator co-operating apparatus 401is integrated within the gas-depleted fluid production assembly 400. Inthis respect, in some embodiments, for example, the apparatus 401 isintegratable within the gas-depleted fluid production assembly 400 suchthat there is established a apparatus-defined flow conductorconfiguration 4011A, and the apparatus-defined flow conductorconfiguration 4011A defines at least a portion of theupwardly-conducting flow conductor configuration 406. In someembodiments, for example, the integration of the apparatus 401 withinthe gas-depleted fluid production assembly 400 is effectuated by adownhole connection configuration 600 and an uphole connectionconfiguration 602. In some embodiments, for example, each one of thedownhole connection configuration 600 and the uphole connectionconfiguration 602, independently, is a threaded connectionconfiguration. In this respect, the apparatus 401 is threaded at eachend.

At least a portion of the apparatus-defined flow conductor configuration4011A includes a flow interference-mitigating conductor configuration4011B. In some embodiments, for example, the flowinterference-mitigating conductor configuration 4011B extends throughthe separation zone-defining wellbore section 4055.

In some embodiments, for example, the flow interference-mitigatingconductor configuration 4011B defines an eccentrically-disposedconductor configuration 4011C. The eccentrically-disposed conductorconfiguration 4011C is disposed eccentrically relative to the centrallongitudinal axis 110X of the wellbore string passage 110.

Referring to FIG. 8 , in some embodiments, for example, theeccentrically-disposed conductor configuration 4011C has a total length“L1” of at least three (3) feet, as measured along the centrallongitudinal axis 4011CX of the eccentrically-disposed conductorconfiguration 4011C. In some embodiments, for example, theeccentrically-disposed conductor configuration 4011C has a total length“L1” of at least six (6) feet. In some embodiments, for example, theeccentrically-disposed conductor configuration 4011C has a total length“L1” of at least 15 feet. In some embodiments, for example, theeccentrically-disposed conductor configuration 4011C has a total length“L1” of at least 20 feet. In some embodiments, for example, theeccentrically-disposed conductor configuration 4011C has a total length“L1” of at least 30 feet.

Referring again to FIG. 8 , in some embodiments, for example, for everycross-section of the wellbore string passage 110 throughout the entireseparation zone-defining wellbore section 4055, there is an absence of aratio, of: (i) the minimum distance “D1” between the centrallongitudinal axis 110X of the wellbore string passage 110, within thecross-section of the wellbore string passage 110, and theeccentrically-disposed conductor configuration 4011C to (ii) the minimumdistance “D2” between the central longitudinal axis 110X of the wellborestring passage 110, within the cross-section of the wellbore stringpassage 110, and the wellbore string 108, that is less than 1:1.2. Insome of these embodiments, for example, the minimum distance “D1” is theperpendicular distance between the central longitudinal axis 110X, ofthe wellbore string passage 110 within the cross-section of the wellborestring passage 110, and the eccentrically-disposed conductorconfiguration 4011C, and the minimum distance “D2” is the perpendiculardistance between the central longitudinal axis 110X, of the wellborestring passage 110 within the cross-section of the wellbore stringpassage 110, and the wellbore string 108.

In some embodiments, for example, throughout the entirety of theeccentrically-disposed conductor configuration 4011C that is extendingthrough the separation zone-defining wellbore section 4055, theeccentrically-disposed conductor configuration 4011C is spaced-apartfrom the wellbore string 108 by a maximum distance “D3” of less than0.75 inches, such as, for example, less than 0.5 inches, such as, forexample, less than 0.25 inches.

Referring to FIG. 9 , in some embodiments, for example, throughout theentirety of the eccentrically-disposed conductor configuration 4011Cthat is extending through the separation zone-defining wellbore section4055, the eccentrically-disposed conductor configuration 4011C has across-sectional profile that is non-circular (e.g. oval-shaped).Configuring the eccentrically-disposed conductor configuration 4011C,such that its cross-sectional profile is non-circular, further mitigatesinterference with the separation, within the space 4055, of thereservoir fluid into the gas-depleted reservoir fluid and thegas-enriched reservoir fluid, by the eccentrically-disposed conductorconfiguration 4011C, and this is more pronounced where thecross-sectional profile of the eccentrically-disposed conductorconfiguration 4011C is oval-shaped and the cross-sectional profile ofthe wellbore string cross-section XC, traversed by theeccentrically-disposed conductor configuration 4011C, is circular.

In some embodiments, for example, the flow interference-mitigatingconductor configuration 4011B co-operates with the wellbore string 108to define a cylindrical unoccupied space 4051. The unoccupied space 4051is space that is unoccupied by the upwardly-conducting flow conductorconfiguration 406. The unoccupied space 4051 occupies at least 70% (suchas, for example, at least 80%) of the total cross-sectional area of across-section 110XC of the wellbore string passage 110 which traversesthe unoccupied space 4051. In some embodiments, for example, the centrallongitudinal axis 110X of wellbore string passage 110 extends throughthe cylindrical unoccupied space 4051. In some embodiments, for example,the unoccupied space 4051 defines a portion of the separation zone 405.Referring to FIG. 8 , in some embodiments, for example, the cylindricalunoccupied space 4051 has a diameter “DD1” of at least one (1) inch(such as, for example, at least 1.5 inches, such as, for example, atleast two (2) inches) and a height “H1” of at least one (1) foot (suchas, for example, at least two (2) feet, such as, for example, at leastthree (3) feet, such as, for example, at least four (4) feet, such as,for example, at least five (5) feet, such as, for example, at least six(6) feet). In some embodiments, for example, the space 4051 is disposedadjacent to the eccentrically-disposed conductor configuration 4011C.

Referring to FIGS. 4 and 7 , in some embodiments, for example, theapparatus 401 includes a flow receiving communicator 4012 (defined byone or more inlet ports), for receiving the upwardly-flowinggas-depleted reservoir fluid flow 708B, and a flow dischargingcommunicator 4013 (defined by one or more outlet ports), for dischargingthe upwardly-flowing gas-depleted reservoir fluid flow 708B for flow tothe suction 300A of the pump 301. Intermediate the flow receivingcommunicator 4012 and the flow discharging communicator 4013, theapparatus 401 includes fluid conductor branches 4014A, 4014B. In thisrespect, the flow receiving communicator 4012 is disposed in flowcommunication with the flow discharging communicator 4013 via the fluidconductor branches 4014A, 4014B. Each one of the fluid conductorbranches 4014A, 4014B, independently, includes a respective one ofbranch portions 4015A, 4015B. The branch portions 4015A, 4015Bco-operate to define the flow interference-mitigating conductorconfiguration 4011B. In this respect, the branch portion 4015A is spacedapart relative to the branch portion 4015B. In some embodiments, forexample, the flow receiving communicator 4012 is defined by a singleinlet port, and the flow discharging communicator 4013 is defined by asingle outlet port, and the integration of the apparatus 401 within thegas-depleted fluid production assembly 400 is effectuated via a downholeconnection and an uphole connection, and, in some of these embodiments,each one of the downhole connection and the uphole connection,independently, is a threaded connection.

By integrating the apparatus 401 within the gas-depleted fluidproduction assembly 400, as described above, fluid communication isestablished between the gas-depleted fluid production assembly 400 andthe pumping assembly 300 for effectuating conducting of the gas-depletedreservoir fluid from the gas-depleted fluid production assembly 400 tothe pumping assembly 300, while, in parallel, establishing aconfiguration of a separation zone 405 for encouraging the separation ofthe reservoir fluid flow 702 into the upwardly-flowing gas-enrichedreservoir fluid flow 706 and the downwardly-flowing gas-depletedreservoir fluid flow 708A.

Referring to FIGS. 1 to 4 , in some embodiments, for example, thegas-depleted fluid production assembly 400 includes a separator 400A.The separator 400A includes a housing 408 and defines aseparator-defined flow conductor configuration 411. Theseparator-defined flow conductor configuration 411 is defined within thehousing 408. In some of these embodiments, for example, the housing 408includes a shroud 412 with a closed bottom 414, such that a space 416 isdefined within the housing 408, and the separator-defined flow conductorconfiguration 411 is defined within the space 416.

The separator-defined flow conductor configuration 411 includes aseparator-defined upwardly-conducting flow conductor configuration(“separator-defined UCFCC”) 406A, and the separator-defined UCFCC 406Adefines a portion of the upwardly-conducting flow conductorconfiguration 406. In some embodiments, for example, theseparator-defined UCFCC 406A is a dip tube. The housing 408 defines agas-depleted reservoir fluid discharging flow communicator 409 (such as,for example, one or more outlet ports). In such embodiments, forexample, the integration of the apparatus 401 within the gas-depletedfluid production assembly 400 is established by: (i) a connection of theapparatus 401 to the gas-depleted reservoir fluid discharging flowcommunicator 409, wherein the connection of the apparatus 401 to thegas-depleted reservoir fluid discharging flow communicator 409 is witheffect that the apparatus-defined flow conductor configuration 4011A isdisposed in flow communication with the separator-defined UCFCC 406A,such that the apparatus-defined flow conductor configuration 4011A isdisposed for receiving the gas-depleted reservoir fluid flow beingconducted by the separator-defined UCFCC 406A, and (ii) a connection ofthe apparatus 401 to the pump suction 301A, wherein the connection ofthe apparatus 401 to the pump suction 301A is with effect that theapparatus-defined flow conductor configuration 406A is disposed forsupplying the gas-depleted reservoir fluid flow to the pumping assembly300. In this respect, a portion of the upwardly-conducting flowconductor configuration 406 is defined by the separator 400A and anotherportion of the upwardly-conducting flow conductor configuration 406 isdefined by the apparatus 401.

In some of these embodiments, for example, each one of the gas-depletedreservoir fluid discharging flow communicator 409 of the housing 408 andthe flow receiving communicator 301AA of the pump suction 301A,independently, is centrally-disposed within the wellbore string 108. Insome embodiments, for example, the gas-depleted reservoir fluiddischarging flow communicator 409 is either one of: (i) co-located withthe central longitudinal axis 110X of the wellbore string passage 110,or (ii) spaced apart, from the central longitudinal axis 110X of thewellbore string passage 110, by a minimum distance of less than 0.125inches from the central longitudinal axis 110X of the wellbore stringpassage 110 (see FIG. 4 ), and, in some of these embodiments, forexample, the minimum distance “D4” is the perpendicular distance betweenthe gas-depleted reservoir fluid discharging flow communicator 409 andthe central longitudinal axis 110X. In some embodiments, for example,the flow receiving communicator 301AA is either one of: (i) co-locatedwith the central longitudinal axis 110X of the wellbore string passage110, or (ii) spaced apart, from the central longitudinal axis 110X ofthe wellbore string passage 110, by a minimum distance of less than0.125 inches from the central longitudinal axis 110X of the wellborestring passage 110, and, in some of these embodiments, for example, theminimum distance is the perpendicular distance between the flowreceiving communicator 301AA and the central longitudinal axis 110X.

Referring to FIGS. 1 and 4 , in some embodiments, for example, thereservoir fluid conductor configuration 403 is defined between thehousing 408 of the separator 400A and the wellbore string 108 (such as,for example, an annular space disposed between the housing 408 and thewellbore string 108), and the separator-defined flow conductorconfiguration 411 further includes the downwardly-conducting flowconductor configuration 404. Referring specifically to FIG. 1 , in someembodiments, for example, the housing 408 defines a separator body 400B,and a flow receiving communicator 418 (e.g. one or more inlet ports) isdefined through an outermost surface 410 of an upper portion of theseparator body 400B, and is effecting flow communication between thereservoir fluid conductor configuration 403 and thedownwardly-conducting flow conductor configuration 404. In some of theseembodiments, for example, the flow receiving communicator 418 isdisposed on a side surface of the separator body 400B. In someembodiments, for example, the separation zone 405 is disposed externallyof the housing 408, and above the flow receiving communicator 418, suchthat the flow receiving communicator 418 is disposed for receiving adownwardly-flowing gas-depleted reservoir fluid flow 708A. In someembodiments, for example, a portion of the separation zone 405 isdisposed externally of the separator 400A and above the flow receivingcommunicator 418, and another portion of the separation zone 405 isdisposed within the space 416 within the housing 408, such that afraction of the separation is effectuated externally of the separator400A and another fraction of the separation is effectuated within theseparator body 400B, and, in some of these embodiments, for example, theseparator body 400A includes a flow-discharging communicator foreffectuating removal of the separated gaseous material from the space216. In either case, the separator 400A and the wellbore string 108 areco-operatively configured such that the downwardly-flowing gas-depletedreservoir fluid 708A becomes emplaced within the space 416 and isconducted downwardly by the downwardly-conducting flow conductorconfiguration 404. The separator-defined UCFCC 406A is disposed in flowcommunication with the downwardly-conducting flow conductorconfiguration 404, and includes a flow receiving communicator 407 forreceiving the gas-depleted reservoir fluid flow 708 conducted by thedownwardly-conducting flow conductor configuration 404. Co-operatively,and as described above, while the gas-depleted reservoir fluid flow 708is being conducted in a downwardly direction by thedownwardly-conducting flow conductor configuration 404, the gas-depletedreservoir fluid flow is diverted such that an upwardly gas-depletedreservoir fluid flow 708 is flowed through the separator-defined UCFCC406A, discharged via the gas-depleted reservoir fluid discharging flowcommunicator 409, and conducted by the apparatus-defined flow conductorconfiguration 4011A to the pump 300. In some of these embodiments, forexample, the separator 400A is a “poor boy separator”.

Referring to FIGS. 2 , in some embodiments, for example, the separator400A further includes a sealed interface effector 420 (e.g. a packermounted to the housing 408), and the sealed interface effector isdisposed in sealing engagement with the wellbore string 108 such that asealed interface 422 is defined. Each one of the reservoir fluidconductor configuration 403 and the separator-defined UCFCC 406A,independently, is defined by the separator 400A, and thedownwardly-conducting flow passage 404 is disposed between the housing408 and the wellbore string 108 (such as, for example, an annular spacedisposed between the separator 400A and the wellbore string 108). Thedownwardly-conducting flow conductor configuration 404, the sealedinterface effector 420, and the upwardly-conducting flow conductorconfiguration 406 are co-operatively configured such that, while agas-depleted reservoir fluid flow 708 is flowing downwardly within thedownwardly-conducting flow conductor configuration 404, thedownwardly-flowing gas-depleted reservoir fluid flow 708A is diverted bythe sealed interface effector 420 with effect that flow of thedownwardly-flowing gas-depleted reservoir fluid flow 708A is divertedsuch that the upwardly-flowing gas-depleted reservoir fluid flow 708B isobtained and is conducted via the separator-defined UCFCC 406A,discharged via the gas-depleted reservoir fluid discharging flowcommunicator 409, and conducted by the apparatus-defined flow conductorconfiguration 4011A to the pump 301. In some of these embodiments, forexample, the separator 400A is a “packer-type gas separator”. In some ofthese embodiments, for example, the separator 400A includes a body 424and a velocity string 426. The body 424 defines a portion of theseparator-defined UCFCC 406A, and also defines a portion of thereservoir fluid conductor configuration 403. The velocity string 426defines another portion of the reservoir fluid conductor configuration403. In this respect, a portion of the reservoir fluid conductorconfiguration 403 is defined by the body 424, and another portion of thereservoir fluid configuration 403 is defined by the velocity string 426.The portion of reservoir fluid conductor configuration 403, which isdefined by the body 424, is a body-defined conductor configuration 430,and the portion of reservoir fluid conductor configuration 403, which isdefined by the velocity string 426, is the flow passage 428 defined bythe velocity string 426. The velocity string 426 includes aflow-receiving communicator 431 (e.g. an inlet port) for receivingreservoir flow from the subterranean formation 100, and is disposed inflow communication with the body-defined conductor configuration 430 viaa flow receiving communicator 427 (defined by one or more inlet ports)defined within the body 424. The body-defined conductor configuration430 defines a flow-discharging communicator 434 (defined by one or moreoutlet ports) for discharging reservoir fluid, being conducted via thebody-defined conductor configuration, into the separation zone 405. Thevelocity string 426 and the body 424 are co-operatively configured suchthat, while reservoir fluid is being received by the flow-receivingcommunicator 431, the reservoir fluid is conducted upwardly via, insuccession, the velocity string passage 428 and the body-definedconductor configuration 430, and discharged into the separation zone405.

Referring specifically to FIG. 3 , in some embodiments, for example, thegas-depleted fluid production assembly 400 within which the apparatus isintegratable is the gas-depleted fluid production assembly 400 disclosedin International Publication No. 2021/258211 (publication ofInternational Application No. PCT/CA2021/050870). In some of theseembodiments, for example, the uphole connection configuration 602 is aconnection to the pump suction 301A.

Referring to FIG. 6 , in some embodiments, for example, the separator400A is supported by an elongated member 800 connected to a portion ofthe apparatus-defined flow conductor configuration 4011A. In some ofthese embodiments, for example, the connection of the elongated member800 to the apparatus-defined flow conductor configuration 4011A is to aportion of the apparatus-defined flow conductor configuration 4011Adisposed above the flow interference-mitigating conductor configuration4011B, such that the elongated member 800 extends past the flowinterference-mitigating conductor configuration 4011B in a spaced apartrelationship relative to the flow interference-mitigating conductorconfiguration 4011B. In some embodiments, for example, the elongatedmember 800 is connected to the flow interference-mitigating conductorconfiguration 4011B with a plurality of gusset braces 802. In thisrespect, for each one of the gusset braces 802, independently, thegusset brace 702 connects a respective portion of the elongated member800 to a counterpart portion of the flow interference-mitigatingconductor configuration 4011B. In some embodiments, for example, theelongated member is in the form of a rigid bar. In some embodiments, forexample, the rigid bar has a maximum cross-sectional area of less than0.5 square inches. In some embodiments, for example, the member 800 isprovided to increase structural strength. In some embodiments, forexample, the member 800 is provided to oppose a bending moment.

Referring to FIG. 7 , in those embodiments where the apparatus 401includes a flow receiving communicator 4012 (defined by one or moreports), for receiving the upwardly-flowing gas-depleted reservoir fluidflow 708B, and a flow discharging communicator 4013 (defined by one ormore ports), for discharging the upwardly-flowing gas-depleted reservoirfluid flow 708B for flow to the suction 300A of the pump 301, and,intermediate the flow receiving communicator 4012 and the flowdischarging communicator 4013, the apparatus 401 includes fluidconductor branches 4014A, 4014B, in some of these embodiments, forexample, the branch portion 4104A is connected to the branch 4014B witha plurality of gusset braces 804 In this respect, for each one of thegusset braces 804, independently, the gusset brace 804 connects arespective portion of the branch portion 4014A to a counterpart portionof the branch portion 4014B.

In some embodiments, for example, the apparatus 401 is provided for theintegration within the gas-depleted fluid production assembly 400. Insome embodiments, for example, the apparatus 401 is part of a kit, andthe kit further includes the elongated member 800 for connection at thework site to effectuate the supporting of the separator 400A.

In some embodiments, for example, a method is provided and includesproducing hydrocarbon material with the system 10. The method furtherincludes suspending the producing. While the producing is suspended, themethod further includes integration of the apparatus 401 within thegas-depleted fluid production assembly 400 such that a modified system10A is obtained (see FIGS. 5 to 7 ). In some embodiments, for example,after the modifying, hydrocarbon material is produced from thesubterranean formation via the modified system 10A.

In some embodiments, for example, prior to the integration, theproduction string is removed from the wellbore 102, and the integrationis effectuated at surface. Once the integration is completed such that amodified production string is obtained, the modified production stringis deployed within the wellbore 102, and hydrocarbon material is thenfurther produced from the subterranean formation.

In some embodiments, for example, the modification is with effect that aflow-interfering flow conductor configuration 406A, of theupwardly-conducting flow conductor configuration, is replaced by atleast a portion of the flow interference-mitigating conductorconfiguration 4011B of the apparatus 401. The flow-interfering flowconductor configuration 406A defines at least a portion of theupwardly-conducting flow conductor configuration 406. In someembodiments, for example, the flow-interfering flow conductorconfiguration 406A is centrally-disposed within the wellbore string 108.In some embodiments, for example, the flow-interfering flow conductorconfiguration 406A is either one of: (i) co-located with the centrallongitudinal axis 110X of the wellbore string passage 110, or (ii)spaced apart, from the central longitudinal axis 110X of the wellborestring passage 110, by a minimum distance of less than 0.125 inches fromthe central longitudinal axis 110X of the wellbore string passage 110,and, in some of these embodiments, for example, the minimum distance isthe perpendicular distance between the flow-interfering flow conductorconfiguration 406A and the central longitudinal axis 110X.

In some embodiments, for example, the modification is with effect thatimproved gas separation characteristics are obtained.

In the above description, for purposes of explanation, numerous detailsare set forth in order to provide a thorough understanding of thepresent disclosure. Although certain dimensions and materials aredescribed for implementing the disclosed example embodiments, othersuitable dimensions and/or materials may be used within the scope ofthis disclosure. All such modifications and variations, including allsuitable current and future changes in technology, are believed to bewithin the sphere and scope of the present disclosure. Therefore, itwill be understood that certain adaptations and modifications of thedescribed embodiments can be made and that the above discussedembodiments are considered to be illustrative and not restrictive. Allreferences mentioned are hereby incorporated by reference in theirentirety.

1-29. (canceled)
 30. A downhole apparatus configured for integrationwithin a gas-depleted fluid production assembly of a reservoir fluidproduction assembly disposed within a wellbore string passage of awellbore string that is emplaced within a wellbore, the integration iswith effect that a apparatus-defined flow conductor configuration isestablished; wherein: the gas-depleted fluid production assemblyco-operates with the wellbore string to define a flow diverter; the flowdiverter defines a reservoir fluid conductor configuration, a separationzone, a downwardly-conducting flow conductor configuration, and anupwardly-conducting flow conductor configuration; the reservoir fluidconductor configuration, the separation zone, the downwardly-conductingflow conductor configuration, and the upwardly-conducting flow conductorconfiguration are co-operatively configured such that: while reservoirfluid flow is being received within a reservoir fluid-receiving zone, ofthe wellbore string passage, from the subterranean formation, thereservoir fluid flow is conducted upwardly to the gas separation zonevia the reservoir fluid conductor configuration, with effect that thereservoir fluid flow becomes emplaced within the separation zone; whilethe reservoir fluid flow is disposed within the separation zone, inresponse to buoyancy forces, gaseous material is separated from thereservoir fluid flow, with effect that an upwardly-flowing gas-enrichedreservoir fluid flow and a downwardly-flowing gas-depleted reservoirfluid flow are obtained, and such that the downwardly-flowinggas-depleted reservoir fluid flow is received and conducted by thedownwardly-conducting flow conductor configuration; and while thegas-depleted reservoir fluid flow is being conducted in a downwardlydirection by the downwardly-conducting flow conductor configuration, thegas-depleted reservoir fluid flow is diverted such that an upwardlygas-depleted reservoir fluid flow is being conducted through theupwardly-conducting flow conductor configuration for suppling a pumpingassembly of the reservoir fluid production assembly; the separation zoneextends through a separation zone-defining wellbore section that extendsfrom a lower wellbore cross section to an upper wellbore cross section;the apparatus-defined flow conductor configuration defines at least aportion of the upwardly-conducting flow conductor configuration; atleast a portion of the apparatus-defined flow conductor configurationincludes a flow interference-mitigating conductor configuration thatextends through the separation zone-defining wellbore section; and theflow interference-mitigating conductor configuration defines aneccentrically-disposed conductor configuration, wherein theeccentrically-disposed conductor configuration is disposed eccentricallyrelative to the central longitudinal axis of the wellbore stringpassage.
 31. The apparatus as claimed in claim 30; wherein: theeccentrically-disposed conductor configuration has a total length “L1”of at least three (3) feet, as measured along the central longitudinalaxis of the eccentrically-disposed conductor configuration.
 32. Theapparatus as claimed in claim 31; wherein: throughout the entirety ofthe eccentrically-disposed conductor configuration that is extendingthrough the separation zone-defining wellbore section, theeccentrically-disposed conductor configuration is spaced-apart from thewellbore string by a maximum distance “D3” of less than 0.75 inches. 33.The apparatus as claimed in claim 30; wherein: the flowinterference-mitigating conductor configuration co-operates with thewellbore string to define a cylindrical unoccupied space, that isunoccupied by the upwardly-conducting flow conductor configuration, andoccupies at least 70% of the total cross-sectional area of across-section of the wellbore string passage which traverses theunoccupied space.
 34. The apparatus as claimed in claim 33; wherein: theunoccupied space defines a portion of the separation zone.
 35. Theapparatus as claimed in claim 34; wherein: the cylindrical unoccupiedspace has a diameter “DD1” of at least one (1) inch and a height “H1” ofat least one (1) foot.
 36. The apparatus as claimed in claim 30, furthercomprising: a flow receiving communicator, for receiving theupwardly-flowing gas-depleted reservoir fluid flow; a flow dischargingcommunicator, for discharging the upwardly-flowing gas-depletedreservoir fluid flow for flow to the pumping assembly; fluid conductorbranches, disposed between the flow receiving communicator and the flowdischarging communicator, such that the flow receiving communicator isdisposed in flow communication with the flow discharging communicatorvia the fluid conductor branches; wherein: each one of the fluidconductor branches, independently, includes a respective one of branchportions; and the branch portions co-operate to define the flowinterference-mitigating conductor configuration.
 37. The apparatus asclaimed in claim 30; wherein: the integration, for which the apparatusis configured is effectuated by a downhole connection configuration andan uphole connection configuration; and each one of the downholeconnection configuration and the uphole connection configuration,independently, is a threaded connection configuration.
 38. The apparatusas claimed in claim 30; wherein: the separator is packer-type separator.39. The apparatus as claimed in claim 30; wherein: the separator is apoor-boy separator.
 40. A kit comprising the apparatus as claimed inclaim 30, and an elongated member for connection to a portion of theapparatus-defined flow conductor configuration and also for connectionto a separator of the gas-depleted fluid production assembly, such that,while the apparatus is integrated within the gas-depleted fluidproduction assembly of a reservoir fluid production assembly, theseparator is supported by the apparatus-defined flow conductorconfiguration.
 41. A method for producing hydrocarbon material, from anoil reservoir within a subterranean formation, via a system includes aproduction string, including a reservoir fluid production assembly,disposed within a wellbore string passage of the wellbore string,wherein the reservoir fluid production assembly includes: a gas-depletedfluid production assembly; and a pumping assembly; wherein: thegas-depleted fluid production assembly co-operates with the wellborestring to define a flow diverter; the flow diverter defines a reservoirfluid conductor configuration, a separation zone, adownwardly-conducting flow conductor configuration, and anupwardly-conducting flow conductor configuration; the reservoir fluidconductor configuration, the separation zone, the downwardly-conductingflow conductor configuration, and the upwardly-conducting flow conductorconfiguration are co-operatively configured such that: while reservoirfluid flow is being received within a reservoir fluid-receiving zone, ofthe wellbore string passage, from the subterranean formation, thereservoir fluid flow is conducted upwardly to the gas separation zonevia the reservoir fluid conductor configuration, with effect that thereservoir fluid flow becomes emplaced within the separation zone; whilethe reservoir fluid flow is disposed within the separation zone, inresponse to buoyancy forces, gaseous material is separated from thereservoir fluid flow, with effect that an upwardly-flowing gas-enrichedreservoir fluid flow and a downwardly-flowing gas-depleted reservoirfluid flow are obtained, and such that the downwardly-flowinggas-depleted reservoir fluid flow is received and conducted by thedownwardly-conducting flow conductor configuration; and while thegas-depleted reservoir fluid flow is being conducted in a downwardlydirection by the downwardly-conducting flow conductor configuration, thegas-depleted reservoir fluid flow is diverted such that an upwardlygas-depleted reservoir fluid flow is being conducted through theupwardly-conducting flow conductor configuration for suppling thepumping assembly; the separation zone extends through a separationzone-defining wellbore section that extends from a lower wellbore crosssection to an upper wellbore cross section; the gas-depleted fluidproduction assembly includes a separator; the separator defines aseparator-defined flow conductor configuration the separator-definedflow conductor configuration includes a separator-definedupwardly-conducting flow conductor configuration (“separator-definedUCFCC”), and the separator-defined UCFCC defines a portion of theupwardly-conducting flow conductor configuration; and wherein the methodcomprises: producing hydrocarbon material via the system; suspending theproducing; and while the producing is suspended, integrating aseparator-co-operating apparatus within the gas-depleted fluidproduction assembly such that a modified system is obtained; wherein:the separator-co-operating apparatus defines an apparatus-defined flowconductor configuration; at least a portion of the apparatus-definedflow conductor configuration includes a flow interference-mitigatingconductor configuration; the flow interference-mitigating conductorconfiguration defines an eccentrically-disposed conductor configuration;the integration of the separating co-operating apparatus within thegas-depleted fluid production assembly includes emplacement between thepumping assembly and the separator, and is with effect that: theapparatus-defined flow conductor configuration is disposed in flowcommunication with the separator-defined UCFCC, such that theapparatus-defined flow conductor configuration is disposed for receivingthe gas-depleted reservoir fluid flow being conducted by theseparator-defined UCFCC; the apparatus-defined flow conductorconfiguration is disposed for supplying the gas-depleted reservoir fluidflow to the pumping assembly; the flow interference-mitigating conductorconfiguration extends through the separation zone-defining wellboresection; and the eccentrically-disposed conductor configuration isdisposed eccentrically relative to the central longitudinal axis of thewellbore string passage.
 42. The method as claimed in claim 41; wherein:the integrating includes: a threadably connecting the apparatus and theseparator; and a threadably connecting the apparatus and the pumpingassembly.
 43. The method as claimed in claim 41; wherein: the separatoris a poor boy separator.
 44. The method as claimed in claim 41; wherein:the separator is a packer-type separator.
 45. The method as claimed inclaim 41; wherein: the eccentrically-disposed conductor configurationhas a total length “L1” of at least three (3) feet, as measured alongthe central longitudinal axis of the eccentrically-disposed conductorconfiguration.
 46. The method as claimed in claim 41; wherein:throughout the entirety of the eccentrically-disposed conductorconfiguration that is extending through the separation zone-definingwellbore section, the eccentrically-disposed conductor configuration isspaced-apart from the wellbore string by a maximum distance “D3” of lessthan 0.75 inches.
 47. The method claimed in claim 41; wherein: the flowinterference-mitigating conductor configuration co-operates with thewellbore string to define a cylindrical unoccupied space, that isunoccupied by the upwardly-conducting flow conductor configuration, andoccupies at least 70% of the total cross-sectional area of across-section of the wellbore string passage which traverses theunoccupied space.
 48. The apparatus as claimed in claim 47; wherein: theunoccupied space defines a portion of the separation zone.
 49. Theapparatus as claimed in claim 48; wherein: the cylindrical unoccupiedspace has a diameter “DD1” of at least one (1) inch and a height “H1” ofat least one (1) foot.